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Exploration and Production Activities (Unaudited) (Tables) | 12 Months Ended
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Dec. 31, 2013
Oil and Gas In Process Activities [Line Items] |
Capital expenditures related to natural gas and oil producing activities [Table Text Block] | The following table sets forth capitalized costs and accumulated depreciation, depletion and amortization related to oil and natural gas producing activities at December 31:
| 2013 |  | 2012 |  | 2011 |
| (In thousands)
Subject to amortization | $ | 2,893,010 |  | $ | 2,531,562 |  | $ | 2,345,114 |
Not subject to amortization | 124,869 |  | 191,794 |  | 232,462 |
Total capitalized costs | 3,017,879 |  | 2,723,356 |  | 2,577,576 |
Less accumulated depreciation, depletion and amortization | 1,562,116 |  | 1,383,386 |  | 1,229,654 |
Net capitalized costs | $ | 1,455,763 |  | $ | 1,339,970 |  | $ | 1,347,922 |
Note: Net capitalized costs reflect noncash write-downs of the Company's oil and natural gas properties, as discussed in Note 1.
Cost incurred in oil and gas property acquisition, exploration, and development activities disclosure [Table Text Block] | Capital expenditures, including those not subject to amortization, related to oil and natural gas producing activities were as follows:
Years ended December 31, | 2013 |  | * | 2012 |  | * | 2011 |  | *
| (In thousands) |
Acquisitions: |  |  |  |  |  |  |  |  |
Proved properties | $ | 1,817 |  |  | $ | 839 |  |  | $ | 3,999 |  |
Unproved properties | 4,608 |  |  | 31,109 |  |  | 63,354 |  |
Exploration | 26,975 |  |  | 235,906 |  |  | 41,775 |  |
Development | 355,421 |  |  | 275,959 |  |  | 161,647 |  |
Total capital expenditures | $ | 388,821 |  |  | $ | 543,813 |  |  | $ | 270,775 |  |
* Excludes net additions/(reductions) to property, plant and equipment related to the recognition of future liabilities for asset retirement obligations associated with the plugging and abandonment of oil and natural gas wells, as discussed in Note 10, of $(10.7) million, $(200,000) and $(1.8) million for the years ended December 31, 2013, 2012 and 2011, respectively.
Results of operations for oil and gas producing activities disclosure [Table Text Block] | The following summary reflects income resulting from the Company's operations of oil and natural gas producing activities, excluding corporate overhead and financing costs:
Years ended December 31, | 2013 |  | 2012 |  | 2011 |
| (In thousands)
Revenues: |  |  |
Sales to affiliates | $ | 45,099 |  | $ | 35,966 |  | $ | 93,713 |
Sales to external customers | 497,018 |  | 379,647 |  | 348,428 |
Realized gain on commodity derivatives | 173 |  | 33,628 |  | 9,618 |
Unrealized gain (loss) on commodity derivatives | (6,267 | ) | (624 | ) | 1,827 |
Production costs | 144,136 |  | 134,795 |  | 140,606 |
Depreciation, depletion and amortization* | 182,352 |  | 157,078 |  | 139,539 |
Write-downs of oil and natural gas properties | — |  | 391,800 |  | — |
Pretax income (loss) | 209,535 |  | (235,056 | ) | 173,441 |
Income tax expense (benefit) | 75,836 |  | (88,612 | ) | 63,655 |
Results of operations for producing activities | $ | 133,699 |  | $ | (146,444 | ) | $ | 109,786 |
* Includes accretion of discount for asset retirement obligations of $3.6 million, $3.3 million and $3.6 million for the years ended December 31, 2013, 2012 and 2011, respectively, as discussed in Note 10.
Schedule of proved developed and undeveloped oil and gas reserve quantities [Table Text Block] | The changes in the Company's estimated quantities of proved oil, NGL and natural gas reserves for the year ended December 31, 2013, were as follows:
| Oil (MBbls) |  | NGL (MBbls) |  | Natural Gas (MMcf) |  | Total (MBOE) |
Proved developed and undeveloped reserves: |  |  |  |
Balance at beginning of year | 33,453 |  | 7,153 |  | 239,278 |  | 80,486 |
Production | (4,815 | ) | (781 | ) | (28,008 | ) | (10,264 | )
Extensions and discoveries | 13,313 |  | 1,333 |  | 26,428 |  | 19,050 |
Improved recovery | — |  | — |  | — |  | — |
Purchases of proved reserves | — |  | — |  | — |  | — |
Sales of proved reserves | (1,286 | ) | (25 | ) | (40,055 | ) | (7,987 | )
Revisions of previous estimates | 354 |  | (1,078 | ) | 802 |  | (590 | )
Balance at end of year | 41,019 |  | 6,602 |  | 198,445 |  | 80,695 |
Significant changes in proved reserves for the year ended December 31, 2013, include:
• | Extensions and discoveries of 19.1 MMBOE, primarily due to drilling activity and new PUD locations at the Company's Bakken and Paradox Basin properties, as well as new PUD locations at Big Horn and East Texas
• | Sales of proved reserves of (8.0) MMBOE, primarily at the Company's Green River Basin property
The changes in the Company's estimated quantities of proved oil, NGL and natural gas reserves for the year ended December 31, 2012, were as follows:
| Oil (MBbls) |  | NGL (MBbls) |  | Natural Gas (MMcf) |  | Total (MBOE) |
Proved developed and undeveloped reserves: |  |  |  |
Balance at beginning of year | 27,005 |  | 7,342 |  | 379,827 |  | 97,651 |
Production | (3,694 | ) | (828 | ) | (33,214 | ) | (10,058 | )
Extensions and discoveries | 9,874 |  | 1,817 |  | 18,386 |  | 14,756 |
Improved recovery | — |  | — |  | — |  | — |
Purchases of proved reserves | — |  | — |  | — |  | — |
Sales of proved reserves | (39 | ) | — |  | (2,307 | ) | (423 | )
Revisions of previous estimates | 307 |  | (1,178 | ) | (123,414 | ) | (21,440 | )
Balance at end of year | 33,453 |  | 7,153 |  | 239,278 |  | 80,486 |
Significant changes in proved reserves for the year ended December 31, 2012, include:
• | Extension and discoveries of 14.8 MMBOE primarily due to drilling activity at the Company's Bakken, South Texas and Paradox properties
• | Revisions of previous estimates of (21.4) MMBOE, largely the result of lower natural gas prices resulting in a reduction of PDP and PUD reserves principally in the Company's Coalbed, Baker, Bowdoin, East Texas and Green River Basin natural gas properties
The changes in the Company's estimated quantities of proved oil, NGL and natural gas reserves for the year ended December 31, 2011, were as follows:
| Oil (MBbls) |  | NGL (MBbls) |  | Natural Gas (MMcf) |  | Total (MBOE) |
Proved developed and undeveloped reserves: |  |  |  |
Balance at beginning of year | 25,666 |  | 7,201 |  | 448,397 |  | 107,599 |
Production | (2,724 | ) | (776 | ) | (45,598 | ) | (11,099 | )
Extensions and discoveries | 4,717 |  | 1,421 |  | 28,221 |  | 10,842 |
Improved recovery | — |  | — |  | — |  | — |
Purchases of proved reserves | 223 |  | 16 |  | 54 |  | 247 |
Sales of proved reserves | — |  | — |  | — |  | — |
Revisions of previous estimates | (877 | ) | (520 | ) | (51,247 | ) | (9,938 | )
Balance at end of year | 27,005 |  | 7,342 |  | 379,827 |  | 97,651 |
Significant changes in proved reserves for the year ended December 31, 2011, include:
• | Extensions and discoveries of 10.8 MMBOE primarily due to drilling activity at the Company's Bakken and Big Horn properties
• | Revisions of previous estimates of (9.9) MMBOE, largely the result of a reduction in PUD reserves of 8.9 MMBOE resulting principally in the Company's Bowdoin, Baker, Coalbed, East Texas and Big Horn Basin properties. The remaining negative revisions were a reduction in PDP natural gas reserves.
The following table summarizes the breakdown of the Company's proved reserves between proved developed and PUD reserves at December 31:
| 2013 |  | 2012 |  | 2011 |
Proved developed reserves: |  |  |
Oil (MBbls) | 31,394 |  | 27,412 |  | 23,653 |
NGL (MBbls) | 5,322 |  | 5,342 |  | 5,225 |
Natural Gas (MMcf) | 176,546 |  | 218,259 |  | 303,495 |
Total (MBOE) | 66,140 |  | 69,131 |  | 79,460 |
PUD reserves: |  |  |
Oil (MBbls) | 9,625 |  | 6,041 |  | 3,352 |
NGL (MBbls) | 1,280 |  | 1,811 |  | 2,117 |
Natural Gas (MMcf) | 21,899 |  | 21,019 |  | 76,332 |
Total (MBOE) | 14,555 |  | 11,355 |  | 18,191 |
Total proved reserves: |  |  |
Oil (MBbls) | 41,019 |  | 33,453 |  | 27,005 |
NGL (MBbls) | 6,602 |  | 7,153 |  | 7,342 |
Natural Gas (MMcf) | 198,445 |  | 239,278 |  | 379,827 |
Total (MBOE) | 80,695 |  | 80,486 |  | 97,651 |
Standardized measure of discounted future cash flows relating to proved reserves disclosure [Table Text Block] | The standardized measure of the Company's estimated discounted future net cash flows of total proved reserves associated with its various oil and natural gas interests at December 31 was as follows:
| 2013 |  | 2012 |  | 2011 |
| (In thousands)
Future cash inflows | $ | 4,507,000 |  | $ | 3,696,200 |  | $ | 4,188,000 |
Future production costs | 1,734,800 |  | 1,536,500 |  | 1,560,300 |
Future development costs | 403,000 |  | 301,600 |  | 285,300 |
Future net cash flows before income taxes | 2,369,200 |  | 1,858,100 |  | 2,342,400 |
Future income tax expense | 545,200 |  | 304,900 |  | 531,100 |
Future net cash flows | 1,824,000 |  | 1,553,200 |  | 1,811,300 |
10% annual discount for estimated timing of cash flows | 810,000 |  | 669,800 |  | 832,500 |
Discounted future net cash flows relating to proved oil, NGL and natural gas reserves | $ | 1,014,000 |  | $ | 883,400 |  | $ | 978,800 |
The following are the sources of change in the standardized measure of discounted future net cash flows by year:
| 2013 |  | 2012 |  | 2011 |
| (In thousands)
Beginning of year | $ | 883,400 |  | $ | 978,800 |  | $ | 896,100 |
Net revenues from production | (398,000 | ) | (280,800 | ) | (301,500 | )
Net change in sales prices and production costs related to future production | 162,200 |  | (406,300 | ) | 82,300 |
Extensions and discoveries, net of future production-related costs | 366,500 |  | 355,300 |  | 226,300 |
Improved recovery, net of future production-related costs | — |  | — |  | — |
Purchases of proved reserves, net of future production-related costs | — |  | — |  | 9,500 |
Sales of proved reserves | (37,800 | ) | (2,600 | ) | — |
Changes in estimated future development costs | 6,700 |  | 37,600 |  | 51,100 |
Development costs incurred during the current year | 141,500 |  | 77,700 |  | 56,300 |
Accretion of discount | 94,600 |  | 121,400 |  | 105,000 |
Net change in income taxes | (141,400 | ) | 110,000 |  | (55,800 | )
Revisions of previous estimates | (55,800 | ) | (100,700 | ) | (92,900 | )
Other | (7,900 | ) | (7,000 | ) | 2,400 |
Net change | 130,600 |  | (95,400 | ) | 82,700 |
End of year | $ | 1,014,000 |  | $ | 883,400 |  | $ | 978,800 |

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- Definition Tabular disclosure of the future net cash flows relating to proved oil and gas reserves and oil and gas subject to purchase under long-term agreements in which the enterprise participates in the operation of the properties on which the oil and gas is located or otherwise serves as the producer. This information is presented in aggregate and for each geographic area for which reserve quantities are disclosed. + References Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 932 -SubTopic 235 -Section 50 -Paragraph 36 -URI http://asc.fasb.org/extlink&oid=8451039&loc=d3e62536-109447 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 932 -SubTopic 235 -Section 50 -Paragraph 30 -URI http://asc.fasb.org/extlink&oid=8451039&loc=d3e62424-109447 Reference 3: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 932 -SubTopic 235 -Section 50 -Paragraph 33 -URI http://asc.fasb.org/extlink&oid=8451039&loc=d3e62479-109447 Reference 4: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 932 -SubTopic 235 -Section 50 -Paragraph 31 -URI http://asc.fasb.org/extlink&oid=8451039&loc=d3e62455-109447 Reference 5: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 932 -SubTopic 235 -Section 50 -Paragraph 35 -URI http://asc.fasb.org/extlink&oid=8451039&loc=d3e62500-109447 Reference 6: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 932 -SubTopic 235 -Section 50 -Paragraph 32 -URI http://asc.fasb.org/extlink&oid=8451039&loc=d3e62476-109447 + Details
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